Method and System to Protect Legacy Production and to Mitigate the Risk of an Uncontrolled Release from Oil and Gas Wells

ABSTRACT

A tool system is provided that can seal perforations or entrance points in a wellbore and reinforce the structure of the wellbore in a single run before a new, nearby wellbore is drilled and stimulated. Embodiments of the present invention comprise a body and bladder combination that is lowered into a wellbore to a predetermined position. In some embodiments, the bladder is positioned around an outer surface of the body and then inflated to seal and reinforce the wellbore. In various embodiments, the bladder is positioned in the body and then flushed to a second predetermined position and filled with a fluid to seal perforations and reinforce the wellbore. A two-reel system can be used to lower the combined body and bladder as well as only the bladder. The bladder-on-body embodiments and the bladder-in-body embodiments can be used in either vertical or horizontal wellbores.

RELATED APPLICATIONS

This application claims the benefit of U.S. Provisional Patent Application No. 62/468,075 filed Mar. 7, 2017 entitled “Method and System to Protect Legacy Production and to Mitigate the Risk of an Uncontrolled Release from Oil and Gas Wells,” which application is incorporated herein by reference in its entirety.

FIELD OF THE INVENTION

This disclosure relates generally to the field of well operations, and more particularly to method and system for lining a wellbore or tubular to protect the integrity of the well.

BACKGROUND OF THE INVENTION

Oil and gas wells extend from the surface to one or more underground formations of rock containing oil and/or gas. The wellbore is typically cased to stabilize the sides of the well, to prevent pollution of fresh water reservoirs, and to prevent fluids from zones other than the oil and gas producing zones from entering the well. Typically, the casing is cemented into the wellbore.

At the oil and gas production zones, the casing is perforated to allow oil, gas and/or by-products to enter the casing. Perforation is typically formed in the casings with shaped explosive charges or projectiles from a perforating gun. Fluids entering the casings through perforations are produced to the surface or otherwise processed. Alternative fracturing techniques include sleeve systems where sleeves are located at periodic intervals in the well. A ball is sent down the wellbore to engage a sleeve, and this engagement causes the pressurized downhole fluid to form an entrance point into the adjacent reservoir.

After a production zone is depleted of oil and/or gas, perforations or entrance points for the zone may be sealed to prevent water production into the casing from the depleted zone while production of oil and/or gas continues from other non-depleted zones. Perforations may be sealed using squeezed cement, straddle patch and chemical techniques.

Even though old wells are sealed, new wells can disrupt nearby, old wells. When new wells are being completed, hydraulic fracturing is the most popular method for stimulating the reservoir. This disruption affects old wells by filling the wellbores with frack fluids and proppant, potential loss of these wells due to integrity damages beyond repair, or abandonment of vertical wells due to state regulations. Potentially, millions of dollars in profit is being lost due to old wells being abandoned or damaged with the stimulation of new development.

Recently, there is an increasing proppant load and water volume in frack design. As more slurry is pumped down-hole, the fracture length increases and more rock is propped to create better wells. As the frack length increases, so does the radius of existing producing wells being compromised. Wells a mile away are being disturbed by current fracking methods. Wellbore integrity in numerous horizontal wells has been impaired. In the lateral section of the well, the liner can be parted, separating the path for the oil and gas to flow to surface. The reserves are now left in the ground and the horizontal well is ruined.

Currently, thousands of vertical wells are being plugged and abandoned due to state regulations. Wells that are 1500 feet from the new wells being stimulated should be plugged. This allows new horizontal wells to be fracked in the adjacent area safety. With the enormous vertical well density present in North America, thousands of wells are being abandoned annually. Most of these wells are still making an economical number of hydrocarbons to keep producing. Moreover, sections with a high vertical density incur high costs to prepare for new fracking development. In some cases, it is not economical to develop these sections due to the price of plugging all the verticals. Drilling and completing new wells in these sections are now put on hold until a cheaper alternative is invented.

In states like Colorado, there are many operators with acreage that border a competitor's acreage. As the well density increases, operators are starting to interfere with each other's production, possibly causing legal issues. The issue of wells being disturbed secondary to fracking will only worsen as the U.S. onshore shale plays increase in activity.

Examples of devices and methods for lining wellbores and tubulars can be found in U.S. Pat. No. 7,306,044 and U.S. Publication No. 2015/0267501, which are incorporated herein in their entireties by reference. Further examples may be found in U.S. Pat. No. 6,119,775; U.S. Pat. No. 5,361,836; European Document No. 2205820; U.S. Pat. No. 5,388,648; U.S. Pat. No. 6,896,063; U.S. Pat. No. 8,499,843; U.S. Publication No. 2015/0267500; U.S. Publication No. 2013/0213669; U.S. Publication No. 2017/0159388; U.S. Publication No. 2016/0069141; U.S. Publication No. 2014/0027118; U.S. Publication No. 2013/0248187; which are incorporated herein in their entireties by reference. These devices and methods have several shortcomings, including, for example, the lack of ability to deploy in a horizontal wellbore and the lack of ability to seal all perforations or entrance points in a well.

SUMMARY OF THE INVENTION

The above needs and other needs are addressed by the various embodiments and configurations of the present invention. Embodiments of the present invention can prevent damage to existing wells during the stimulation of new wells, and thus, comply with state regulations. This aspect of the invention provides an operator with the ability to keep many old wellbores operational without having to plug and abandon the wellbores. By protecting the old vertical and horizontal wellbores, millions of barrels of reserves can stay on the reserve books and the base production decline decreases, overall increasing the value of the operating company.

It is a further aspect of embodiments of the present invention to provide an environmentally-friendly apparatus to incur the benefits described herein. Components of the tool system described herein can be stored on a reel system, which is transported on a truck or trailer. The tool system, therefore, has a small footprint when deployed next to a wellbore, and there is no need to move any dirt or expand the well pad to make room for equipment. This is more environmentally friendly when compared to using large amounts of equipment on a location to plug or workover a well.

Various embodiments of the present invention include a bladder that expands in the wellbore, covering perforations or entrance points. The bladder would divert any fluid, proppant or reservoir elements that could enter the wellbore. With the tool system expanded in the wellbore, the structural integrity of the well increases. The inflated bladder will keep the casing from shifting and parting. The tool itself can be a steel reinforced hose or a coil string that is wrapped and transported on a reel. The lower half of the hose/coil can be covered with an elastomer molding, which can expand like a balloon. The tool is ran in and out of the hole like wireline. The elastomer bladder material used is similar to the rubber utilized for downhole packers; durable enough to deflect frac pressures, and able to withstand the stress and tensile strain of running in and out of the well. Also, the materials used to make this tool will withstand temperatures from −50 to 250° F. The upper half of the hose may not expand in some embodiments, and the segment of the hose that is under the bladder may have ports for the fluid to be transported back and forth from the bladder.

A siphon tube can be located within the hose and can act like a straw. Fluids can be pumped down the string, inflating the bladder, then the fluid can be sucked out of the bladder through this siphon hose. As one pumps fluid from surface, the fluid will go down the siphon hose and out of the ports into the bladder, expanding the rubber inside the wellbore and creating a seal. Located at the bottom of the bladder are steel elements that will expand with the bladder. Sharp grooves can be cut into the steel element that will allow the tool to bite into the casing, holding the tool in place.

The diameter of the hose is important, appropriately sized to run in and out of the tubing. Tubing will not have to be pulled, which will save money and time. If the tubing string lands too close to the perforations, then the tubing should be pulled. The diameter will be large enough to pump fluid down at a sufficient rate. There can be a siphon sting in the hose/coil to allow the fluid to be pumped out of the bladder. There should be no reason to introduce external fluids into the reservoir, protecting the well from reservoir damages; making it easier to get the well back online and producing. Below is an example of a possible scenario. There is a vertical well with two zones perforated. The goal is to make a seal over all entrance points to prevent a frack into the vertical well when a neighboring well is being fracked.

The tool was run into the well, the bladder was inflated, and both zones are covered. Now, new wells surrounding this vertical well can be fracked safely. Embodiments of the present invention provide a cheap and safe way to keep this well from being harmed without being plugged.

It is a further aspect of embodiments of the present invention to provide a device, method, or system that can deploy into a wellbore and seal or reinforce all perforations or entrance points in a wellbore. The components described herein can be appropriately sized to seal all perforations or entrance points, and thus, embodiments of the present invention can seal the entire well in one run, saving time and costs.

One particular embodiment of the present invention is a tool system for deploying an inflatable member in a wellbore, comprising a reel system having a first reel and a second reel, wherein a locking mechanism selectively connects and disconnects the first reel and the second reel; a body connected to the reel system, the body having an internal volume; an inflatable member; a cable connected to the inflatable member and the reel system, wherein the inflatable member and cable are configured to be positioned in the internal volume of the body; wherein, in a first mode of operation, the locking mechanism connects the first reel and the second reel such that the first reel can unwind the body, the inflatable member, and the cable in a wellbore; and wherein, in a second mode of operation, the locking mechanism disconnects the first reel and the second reel such that the second reel can continue to unwind the inflatable member and the cable through the body and into the wellbore.

In some embodiments, a proximal end of the body is connected to the first reel, and a proximal end of the cable is connected to the second reel. In various embodiments, a length of the body is less than a combined length of the cable and the inflatable member. In some embodiments, in the first mode of operation, a distal end of the inflatable member is connected to a distal end of the body.

In various embodiments, the inflatable member is configured to expand from a first diameter to a larger second diameter to contact an inner surface of the wellbore. In some embodiments, a diameter of the first reel is larger than a diameter of the second reel. In various embodiments, in the first mode of operation, a proximal end of the inflatable member is connected to a distal end of the cable.

Another particular embodiment of the present invention is a method for deploying an inflatable member in a wellbore, comprising (i) providing a tool system having a reel system, a body connected to the reel system, an inflatable member, and a cable connected to the inflatable member and the reel system, wherein the inflatable member and cable are positionable in the body; (ii) lowering, by the reel system, the body, the inflatable member, and the cable into a wellbore to a first predetermined depth; (iii) lowering, by the reel system, the inflatable member and the cable further into the wellbore to a second predetermined depth; and (iv) inflating the inflatable member from a first diameter to a second diameter so that the inflatable member contacts an inner surface of the wellbore.

In various embodiments, the method further comprises (v) pushing the inflatable member from the body using a fluid pumped into an annulus of the body. In some embodiments, the method further comprises (vi) inflating the inflatable member with a fluid pumped through the body. In some embodiments, the reel system comprises a first reel and a second reel, wherein the body is connected to the first reel, and the cable is connected to the second reel. In various embodiments, the method further comprises (vii) uncoupling the first and second reels prior to lowering the inflatable member and the cable further into the wellbore to the second predetermined depth.

In some embodiments, the method further comprises (viii) unreeling the first and second reels to lower the body, the inflatable member, and the cable into the wellbore to the first predetermined depth; and (ix) unreeling the second reel to lower the inflatable member and the cable further into the wellbore to the second predetermined depth. In various embodiments, a length of the body is smaller than a combined length of the cable and the inflatable member.

Yet another particular embodiment of the present invention is a tool system for deploying an inflatable member in a wellbore, comprising a reel; a body connected to the reel, the body having an outer surface and a length; an inflatable member positioned on the outer surface of the body, the inflatable member extending along at least a portion of the length of the body; at least one port of the body, the at least one port providing fluid communication between an interior of the body and an exterior of the body, wherein the inflatable member is positioned over the at least one port, and wherein the bladder is configured to receive a fluid through the at least one port to expand the bladder to a larger diameter.

In some embodiments, the tool system further comprises a siphon hose extending through the body, wherein the siphon hose is configured to supply the fluid to the bladder and retrieve the fluid from the bladder. In various embodiments, the inflatable member is an elastomer bladder. In some embodiments, the hose is one of a steel-reinforced hose and a coil string. In some embodiments, the tool system further comprises at least one rigid member positioned on an outer surface of the inflatable member, wherein the at least one rigid member is configured to grip an inner surface of a wellbore as the bladder expands to the larger diameter. In various embodiments, the at least one rigid member is at least one steel element, wherein each steel element has at least one groove.

Another particular embodiment of the present invention is a method for deploying an inflatable member in a wellbore, comprising providing a tool system having a reel system, a body attached to the reel system, a bladder, and a cable attached to the bladder and the reel system, wherein the bladder and cable are positioned in the body; lowering the body, the bladder, and the cable into a wellbore to a first predetermined depth; uncoupling the bladder and the cable from the body; lowering the bladder and the cable further into the wellbore to a second predetermined depth; inflating the bladder from a first diameter to a second diameter so that the bladder contacts an inner surface of the wellbore.

In some embodiments, the method further comprises pushing the bladder from the body using a fluid pumped into an annulus of the body. In various embodiments, the method further comprises inflating the bladder with a fluid pumped through the body.

A further particular embodiment of the present invention is a method to protect an inner wall of a first wellbore when fracking nearby wellbores of the first wellbore, wherein the method comprises filling liquid in a balloon-like structure; positioning the balloon-like structure next to a plurality of perforations of the first wellbore to seal off the plurality of perforations and reinforce the first wellbore; and fracking the nearby wellbores with less of an impact on the first wellbore.

In various embodiments, the first wellbore is old wellbore, and the nearby wellbores are new wellbores. In some embodiments, the fluid required for sealing the perforations comprises of viscosity of 20-25η.

Another particular embodiment of the present invention is an apparatus to protect an inner wall of a first wellbore when fracking nearby wellbores of the first wellbore, wherein the apparatus comprises a spiral coiled tubing that is adapted to hold balloon-like structures near to the first wellbore; a deflating assembly tool that is adapted to lower the balloon-like structures; a holding spatula that is adapted to position the balloon-like structures next to a plurality of perforations in the first wellbore; and a sealing device that is adapted to fill the balloon-like structures with a fluid that seal all the plurality of perforations in the first wellbore.

In some embodiments, the first wellbore is old wellbore and the nearby wellbores are new wellbores. In various embodiments, the deflating assembly tool comprises at least two pressure-operated deflating valves for reducing the pressure of the balloon like structures.

The Summary of the Invention is neither intended nor should it be construed as being representative of the full extent and scope of the present invention. The present invention is set forth in various levels of detail in the Summary of the Invention as well as in the attached drawings and the Detailed Description of the Invention and no limitation as to the scope of the present invention is intended by either the inclusion or non-inclusion of elements or components. Additional aspects of the present invention will become more readily apparent from the Detailed Description, particularly when taken together with the drawings.

The above-described embodiments, objectives, and configurations are neither complete nor exhaustive. As will be appreciated, other embodiments of the invention are possible using, alone or in combination, one or more of the features set forth above or described in detail below.

The phrases “at least one,” “one or more,” and “and/or,” as used herein, are open-ended expressions that are both conjunctive and disjunctive in operation. For example, each of the expressions “at least one of A, B, and C,” “at least one of A, B, or C,” “one or more of A, B, and C,” “one or more of A, B, or C,” and “A, B, and/or C” means A alone, B alone, C alone, A and B together, A and C together, B and C together, or A, B, and C together.

Unless otherwise indicated, all numbers expressing quantities, dimensions, conditions, and so forth used in the specification and claims are to be understood as being modified in all instances by the term “about.”

The term “a” or “an” entity, as used herein, refers to one or more of that entity. As such, the terms “a” (or “an”), “one or more,” and “at least one” can be used interchangeably herein.

The use of “including,” “comprising,” or “having” and variations thereof herein is meant to encompass the items listed thereafter and equivalents thereof as well as additional items. Accordingly, the terms “including,” “comprising,” or “having” and variations thereof can be used interchangeably herein.

It shall be understood that the term “means” as used herein shall be given its broadest possible interpretation in accordance with 35 U.S.C. § 112(f). Accordingly, a claim incorporating the term “means” shall cover all structures, materials, or acts set forth herein, and all of the equivalents thereof. Further, the structures, materials, or acts and the equivalents thereof shall include all those described in the summary of the invention, brief description of the drawings, detailed description, abstract, and claims themselves.

BRIEF DESCRIPTION OF THE DRAWINGS

The accompanying drawings, which are incorporated in and constitute a part of the specification, illustrate embodiments of the invention and together with the Summary of the Invention given above and the Detailed Description of the drawings given below, serve to explain the principles of these embodiments. In certain instances, details that are not necessary for an understanding of the invention or that render other details difficult to perceive may have been omitted. It should be understood, of course, that the invention is not necessarily limited to the particular embodiments illustrated herein. Additionally, it should be understood that the drawings are not necessarily to scale.

FIG. 1 is a cross-sectional view of a horizontal wellbore in accordance with various embodiments of the invention;

FIG. 2 is a cross-sectional view of a vertical wellbore in accordance with various embodiments of the invention;

FIG. 3 is a perspective view of a wellbore tool in a first state in accordance with various embodiments of the invention;

FIG. 4 is a perspective view of the wellbore tool from FIG. 3 in a second state in accordance with various embodiments of the invention;

FIG. 5 is a side elevation view of a reel system in a first state in accordance with various embodiments of the invention; and

FIG. 6 is a side elevation view of the reel system from FIG. 5 in a second state in accordance with various embodiments of the invention.

Similar components and/or features may have the same reference label. Further, various components of the same type may be distinguished by following the reference label by a letter that distinguishes among the similar components. If only the first reference label is used, the description is applicable to any one of the similar components having the same first reference label irrespective of the second reference label.

A list of the various components shown in the drawings and associated numbering is provided herein:

Number Component 10 Wellbore 12 Perforations 14 Tool System 16 Reel System 18 Body 20 Bladder 22 Off-Set Frac 24 Cable 26 Bladder Attachment 28 Fluid 30 First Reel 32 Unreeled Body 34 Second Reel 36 Unreeled Bladder

DETAILED DESCRIPTION

The present invention has significant benefits across a broad spectrum of endeavors. It is the Applicant's intent that this specification and the claims appended hereto be accorded a breadth in keeping with the scope and spirit of the invention being disclosed despite what might appear to be limiting language imposed by the requirements of referring to the specific examples disclosed. To acquaint persons skilled in the pertinent arts most closely related to the present invention, a preferred embodiment that illustrates the best mode now contemplated for putting the invention into practice is described herein by, and with reference to, the annexed drawings that form a part of the specification. The exemplary embodiment is described in detail without attempting to describe all of the various forms and modifications in which the invention might be embodied. As such, the embodiments described herein are illustrative, and as will become apparent to those skilled in the arts, may be modified in numerous ways within the scope and spirit of the invention.

Although the following text sets forth a detailed description of numerous different embodiments, it should be understood that the detailed description is to be construed as exemplary only and does not describe every possible embodiment since describing every possible embodiment would be impractical, if not impossible. Numerous alternative embodiments could be implemented, using either current technology or technology developed after the filing date of this patent, which would still fall within the scope of the claims. To the extent that any term recited in the claims at the end of this patent is referred to in this patent in a manner consistent with a single meaning, that is done for sake of clarity only so as to not confuse the reader, and it is not intended that such claim term by limited, by implication or otherwise, to that single meaning.

Various embodiments of the present invention are described herein and as depicted in the drawings. It is expressly understood that although the figures depict reels, bladders, and wellbores, and methods and systems for using the same, the present invention is not limited to these embodiments. The terms “well” and “wellbore”, and “perforation” and “entrance point” can be used interchangeably herein.

Now referring to FIG. 1, a cross-sectional view of the tool system 14 in a wellbore 10 is provided. The wellbore 10 begins with a vertical orientation, but changes to a horizontal orientation, which is now common with directional drilling. After the wellbore 10 turns horizontal, perforations 12 are created in the sides of the tubular and interior of the wellbore 10 to extract resources. As shown, the tool system 14 generally comprises a reel system 16, a body 18, and a bladder 20 that expands to seal the perforations 12 and reinforce the wellbore 10.

The body 18 and bladder 20 can be gravity fed through the vertical portions of the wellbore but not necessarily the horizontal portions so fluid is used to push the bladder 20 along the horizontal portions toward the toe of the well. In some embodiments, the bladder 20 is transported within the body 18, which can be a hose or coil tubing, down the vertical portion of the well. A distal end of the deflated bladder 20 can be selectively attached to a distal end of the body 18, and a proximal end of the bladder 20 can be attached to a cable, which extends up to the surface of the wellbore 10.

To transport the bladder 20 through the horizontal portion of the wellbore 10, fluid is pumped down an annulus of the body 18. As the fluid is being pumped, the bladder 20 is fed down the body 18 and out into the well, and the cable controls how fast the bladder 20 exits the body 18 of the tool system 14 and into the wellbore. Accordingly, the bladder 20 can cover the perforations 12 in the horizontal portions of the wellbore 10. To help facilitate the fluid pressing the bladder 20 out of the body 18 and into the wellbore, a friction reducing agent can be added to the fluid. The friction reducing agent lubricates the interface between the outer surface of the bladder 20 and the inner surface of the wellbore or casing, and therefore, reduces the friction coefficient between these two surfaces.

Several additional features or components can aid in operation of the tool system 14. A safety valve can generally control fluid flow, a bleed valve can allow air to escape when the bladder is filled or can be used to let fluid pass to contact the bladder at the end of the job, and a siphon valve can open and close to control fluid flow into the tool.

Next, a lubricator can be attached to the top of the wellbore, and the lubricator can serve as the pressure equalization point from the well to the tool. The body and bladder run through the lubricator before entering the wellbore. An injector can be positioned above the lubricator if the wellbore has high pressure formations. The injector grips the body and/or bladder to force the tool system components down into the wellbore.

Now referring to FIG. 2, a cross-sectional view of the tool system 14 in a vertical wellbore is provided. The deployment procedure can be the same as in a horizontal wellbore where the body 18 is lowered into the wellbore to a predetermined depth, and then the bladder 20 is deployed to cover perforations 12 or a structure feature 22 such as an offset frac. In some embodiments, the bladder 20 can be twice as long as the body 18 of the tool system 14, and the bladder 20 can, for example, cover a two mile long section of wellbore.

It will be appreciated that in some embodiments, the bladder 20 is positioned outside of the body 18. Therefore, the body 18 and the bladder 20 can be directly positioned over perforations and/or other portions of a well, and the bladder 20 would inflate off of the body 18. The bladder-in-body embodiments and the bladder-on-body embodiments can be used in either vertical or horizontal wellbores, but preferably, the bladder-in-body embodiments are used in horizontal wellbores, and the bladder-on-body embodiments are used in vertical wellbores.

It will be further appreciated that the body 18 can be made of rigid material such as, for example, any metallurgical alloy to form a coil tubing such as steel, aluminum, copper, tin, etc.; and the body 18 can be forced through vertical and horizontal portions of a wellbore. It will also be appreciated that the body 18 can be made of non-rigid material such as, for example, rubber, rubber reinforced with steel band (inside or outside of the rubber), carbon fiber, etc. In addition, the bladder can be any material like rubber, plastics, or elastomer that can expand from a first diameter to a second diameter to seal perforations and/or reinforce a wellbore.

Now referring to FIGS. 3 and 4, a perspective view of the deployment of the bladder 20 from the body 18 is provided. Referring to FIG. 3, the bladder 20 is housed within the body 18, and a proximal end of the bladder 20 is connected to a cable 24, which runs to the surface of the wellbore. The distal end of the bladder 20 can have a bladder attachment feature 26 that selectively connects the bladder 20 to the body 18. As shown in FIG. 4, fluid 28 can be pumped down the body to push the bladder 20 out of the body 18 and fill the bladder 20 with fluid 28 so that the bladder 20 seals the inner surface of the wellbore and reinforces the wellbore. Many different fluids can be used to inflate the bladder 20. It will be appreciated that water, brine water, produced water from a well, crude oil, other types of oil, ambient air, nitrogen, natural gas, or any other type of compressible or incompressible fluid can be used to inflate the bladder 20.

Additional features can be positioned on the bladder 20 and/or the body 18 to add functionality to the tool system 14. For instance, a rupture disk could be placed at the end of the tool 14. The disk can to burst to eject fluid out of the bottom of the tool 14 and into the well. This could be a safety precaution if pressures exceed a predetermined threshold. Or if the fluid cannot be pumped back to the surface. The pressure could be increased until the port bursts then the tool system 14 can be reeled back to surface. Further, a weight bar can be attached to the tool system 14 to facilitate the tool system 14 traveling through the wellbore.

Now referring to FIGS. 5 and 6, elevation views of a reel system 16 are provided. The reel system 16 lowers the body and the bladder into the wellbore. However, as noted above, in some embodiments, the bladder is longer than the body so the reel system 16 should accommodate this aspect of the tool system 14. As shown in FIG. 5, this embodiment has a reel-in-reel design with a first reel 30 and a second reel 34. During operation, the reels 30, 34 can rotate together and a combined unreeled body 32 and unreeled bladder 36 are lowered into the wellbore. When, for example, the combined body and bladder reach the horizontal portion of the well, the first reel 30 can stop and the second reel 34 can continue to rotate and continue to lower the bladder and cable into the horizontal section of the wellbore. A pin can be used in some embodiments to change between a two reel mode and a single reel mode.

Once the bladder reaches the toe of the well, the bladder is inflated with fluid to seal perforations and reinforce the wellbore. The tool can stay in the well while the new wells are fracked nearby. To reverse this procedure, the fluid can be pumped out of the bladder or released into the well. Then, the second reel 34 rotates to retract the cable and the bladder. Then, once the distal end of the bladder reaches the distal end of the body, the two reels 30, 34 can be pinned together to rotate in unison and retract the bladder and the body. In some embodiments, the fluid or fluids used to inflate the bladder are not exposed to the reservoir of natural resources, which allows for a quick turnaround.

It will be appreciated that the features and components of the tool system 14 may have various dimensions and characteristics. For instance, the bladder and/or body may have a diameter between approximately 0.0001″ to 10000″, more particularly between approximately 1″ to 3″, and even more specifically between approximately 2″ to 3″. The bladder, in some embodiments, can expand up to 20″ in diameter, and more particularly, between approximately 4″ and 7″. The length of the one or both of the bladder and body can be between approximately 5′ and 50,000′, and in some embodiments, approximately 12,000′ or 20,000′. The features and components of the tool system 14 should also withstand reservoir temperatures between 100 to 250° F., ambient temperatures down to −40° F., and generally between −50 to 300° F.

The description of the present invention has been presented for purposes of illustration and description, but is not intended to be exhaustive or limiting of the invention to the form disclosed. Many modifications and variations will be apparent to those of ordinary skill in the art. The embodiments described and shown in the figures were chosen and described in order to best explain the principles of the invention, the practical application, and to enable those of ordinary skill in the art to understand the invention.

While various embodiments of the present invention have been described in detail, it is apparent that modifications and alterations of those embodiments will occur to those skilled in the art. Moreover, references made herein to “the present invention” or aspects thereof should be understood to mean certain embodiments of the present invention and should not necessarily be construed as limiting all embodiments to a particular description. It is to be expressly understood that such modifications and alterations are within the scope and spirit of the present invention, as set forth in the following claims. 

What is claimed is:
 1. A tool system for deploying an inflatable member in a wellbore, comprising: a reel system having a first reel and a second reel, wherein a locking mechanism selectively connects and disconnects the first reel and the second reel; a body connected to the reel system, the body having an internal volume; an inflatable member; a cable connected to the inflatable member and the reel system, wherein the inflatable member and cable are configured to be positioned in the internal volume of the body; wherein, in a first mode of operation, the locking mechanism connects the first reel and the second reel such that the first reel can unwind the body, the inflatable member, and the cable in a wellbore; and wherein, in a second mode of operation, the locking mechanism disconnects the first reel and the second reel such that the second reel can continue to unwind the inflatable member and the cable through the body and into the wellbore.
 2. The tool system of claim 1, wherein a proximal end of the body is connected to the first reel, and a proximal end of the cable is connected to the second reel.
 3. The tool system of claim 1, wherein a length of the body is less than a combined length of the cable and the inflatable member.
 4. The tool system of claim 1, wherein, in the first mode of operation, a distal end of the inflatable member is connected to a distal end of the body.
 5. The tool system of claim 1, wherein the inflatable member is configured to expand from a first diameter to a larger second diameter to contact an inner surface of the wellbore.
 6. The tool system of claim 1, wherein a diameter of the first reel is larger than a diameter of the second reel.
 7. The tool system of claim 1, wherein, in the first mode of operation, a proximal end of the inflatable member is connected to a distal end of the cable.
 8. A method for deploying an inflatable member in a wellbore, comprising: providing a tool system having a reel system, a body connected to the reel system, an inflatable member, and a cable connected to the inflatable member and the reel system, wherein the inflatable member and cable are positionable in the body; lowering, by the reel system, the body, the inflatable member, and the cable into a wellbore to a first predetermined depth; lowering, by the reel system, the inflatable member and the cable further into the wellbore to a second predetermined depth; and inflating the inflatable member from a first diameter to a second diameter so that the inflatable member contacts an inner surface of the wellbore.
 9. The method of claim 8, further comprising: pushing the inflatable member from the body using a fluid pumped into an annulus of the body.
 10. The method of claim 8, further comprising: inflating the inflatable member with a fluid pumped through the body.
 11. The method of claim 8, wherein the reel system comprises a first reel and a second reel, wherein the body is connected to the first reel, and the cable is connected to the second reel.
 12. The method of claim 11, further comprising: uncoupling the first and second reels prior to lowering the inflatable member and the cable further into the wellbore to the second predetermined depth.
 13. The method of claim 11, further comprising: unreeling the first and second reels to lower the body, the inflatable member, and the cable into the wellbore to the first predetermined depth; and unreeling the second reel to lower the inflatable member and the cable further into the wellbore to the second predetermined depth.
 14. The method of claim 8, wherein a length of the body is smaller than a combined length of the cable and the inflatable member.
 15. A tool system for deploying an inflatable member in a wellbore, comprising: a reel; a body connected to the reel, the body having an outer surface and a length; an inflatable member positioned on the outer surface of the body, the inflatable member extending along at least a portion of the length of the body; at least one port of the body, the at least one port providing fluid communication between an interior of the body and an exterior of the body, wherein the inflatable member is positioned over the at least one port, and wherein the bladder is configured to receive a fluid through the at least one port to expand the bladder to a larger diameter.
 16. The tool system of claim 15, further comprising: a siphon hose extending through the body, wherein the siphon hose is configured to supply the fluid to the bladder and retrieve the fluid from the bladder.
 17. The tool system of claim 15, wherein the inflatable member is an elastomer bladder.
 18. The tool system of claim 15, wherein the hose is one of a steel-reinforced hose and a coil string.
 19. The tool system of claim 15, further comprising: at least one rigid member positioned on an outer surface of the inflatable member, wherein the at least one rigid member is configured to grip an inner surface of a wellbore as the bladder expands to the larger diameter.
 20. The tool system of claim 15, wherein the at least one rigid member is at least one steel element, wherein each steel element has at least one groove. 